Abstract: The present invention relates to a fluid circulation system for circulating fluid in a subsea cavity, the cavity being filled with a first fluid and having first and second end ports. The system comprises a container (26) containing a second fluid, fluid lines (21, 27) extending from the container to the first and second end ports of the cavity, respectively, and a pump (22) for exchanging the second fluid provided in the container (26) and the first fluid provided in the subsea cavity (10). The invention also relates to a method for circulating fluid in a subsea cavity.

Abstract: An improved hydrotest testing system comprises a safety stop which prevents the testing tools from being blown out of the top of the tubing string. The safety stop is made up into the upward facing box of the tubing joint to be tested, where the stop is positioned between the tool assembly placed within the tubing joint and the no-go head assembly which is located at the surface during the testing operation. Once the safety stop has been made up into upward facing box, the tool assembly is set within the joint to be tested and the joint pressure tested. The safety stop has a generally cylindrical body which has a bore extending through its length, where the bore has a reduced diameter throat which is sized smaller than portions of the downhole testing tool.

Abstract: A method of servicing hydrocarbon production equipment comprising locating at least a portion of a hydrocarbon flow conduit experiencing a loss of functionality; creating a port to access an interior flow bore of the hydrocarbon flow conduit; installing at least one piece of equipment proximate the access port, wherein the equipment has access to the interior flow bore via the access port; and placing a servicing composition into the conduit via the access port, wherein the servicing composition prevents the loss of materials from the interior of the hydrocarbon flow conduit to the surrounding environment.

Abstract: For use with a top drive power unit supported for connection with a well string in a well bore to selectively impart longitudinal and/or rotational movement to the well string, a feeder for supplying a pumpable substance such as cement and the like from an external supply source to the interior of the well string in the well bore without first discharging it through the top drive power unit including a mandrel extending through a sleeve which is sealably and rotatably supported thereon for relative rotation between the sleeve and mandrel. The mandrel and sleeve have flow passages for communicating the pumpable substance from an external source to discharge through the sleeve and mandrel and into the interior of the well string below the top drive power unit. The unit can include a packing injection system and novel seal configuration.

Abstract: A fill up and circulation tool having an elongate body with an insertion section adapted for insertion into a tubular member, a base section adapted for engagement with a top drive, and a gauge section having a diameter less than that of the base section. A packer cup assembly and at least one spacer can be adjustably associated with the gauge section, the packer cup assembly being positionable at a plurality of locations along the gauge section by placing the packer cup assembly and one or more spacers relative to one another in a desired configuration, such that the packer cup assembly and one or more spacers occupy substantially all of the gauge section. The spacing and configuration of the packer cup assembly along the gauge section can be selected depending on the dimensions or type of top drive, elevator, bails, or other equipment at a worksite.

Abstract: The subject disclosure relates to matrix acidizing. More specifically, the subject disclosure relates to manipulating downhole pressure to promote in-situ mixing. In particular, downhole pressure is temporarily reduced to allow churning of the dissolved CO2 to facilitate mixing efficiency within the wormholes and the matrix around the wormholes.

Abstract: Methods and systems for enhanced oil recovery from a subterranean formation are provided. An exemplary includes separating fluid produced from the subterranean formation into a first fluid stream that includes an aqueous stream containing multivalent ions. At least a portion of the multivalent ions in the first fluid are removed to form a second fluid stream and the second fluid stream is injected into the subterranean formation. The first fluid stream and the second fluid stream have substantially the same interfacial tension with a hydrocarbon and substantially the same kinematic viscosity, and the second fluid stream has a total concentration of ions greater than about 100,000 ppm.

Abstract: Methods and systems for enhancing oil recovery from a subterranean formation comprising at least a first region and a second region are provided. An exemplary method includes creating an injection stream by adding a salt to a water stream to increase a concentration of an ion and injecting the injection stream into the subterranean formation through a first injection well in the first region of the subterranean formation. Fluid is produced from the subterranean formation and separated to generate an aqueous stream comprising at least a portion of the ion. The salt is added to the aqueous stream to adjust the concentration of the ion in the aqueous stream to a desired level. The aqueous stream is injected into the subterranean formation through a second injection well in the second region of the subterranean formation.

Abstract: A system for producing oil and/or gas comprising a mechanism for releasing at least a portion of a sulfur containing compound into a formation; a first mechanism for converting at least a portion of the sulfur containing compound into a carbon disulfide formulation and/or a carbon oxysulfide formulation, the first mechanism for converting within the formation; and a second mechanism for converting at least a portion of the carbon disulfide formulation and/or a carbon oxysulfide formulation into another compound, the second mechanism for converting within the formation.

Abstract: A method, system, and composition for producing oil from a formation utilizing an oil recovery formulation comprising a surfactant, an alkali, a polymer, and a paraffin inhibitor are provided.

Abstract: A lightweight cross-linked gelled settable cement fluid system derived by pre-hydrating a water gelling agent, and then using that to mix with a cement blend which results in a very stable cement blend, which will matriculate through any fluid and not disperse, and form a cohesive plug wherever it comes to rest; wherein the fluid is injected at the bottom of the 10 pound/gal brine, and the fluid rises to the top of the brine where it reforms into a cohesive plug and hardens; and wherein the fluid can be applied to any density solution, and provide stability and cohesiveness to any settable plug; and wherein the cement/gelled water mixture is then cross-linked using standard hydraulic fracturing cross-linkers to provide a stable structure and ability to matriculate through another fluid and not disperse into that fluid.

Abstract: A system for injecting fluids into a well having a fluid supply tine that is connected to a mandrel at the top of the production tree. The system is designed so that all components of the system are packaged together and run to the production tree in one run. The production tree is designed to provide a pathway for the fluid to travel from the mandrel to the production bore within the tree, and then into the production tubing of a well.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment a method of cementing comprising: providing a pozzolan slurry comprising a pozzolan and water; providing a lime slurry comprising hydrated lime and water; allowing the pozzolan slurry and the lime slurry to remain separate for about one day or longer; mixing the pozzolan slurry and the lime slurry to form a cement composition; and allowing the cement composition to set.

Abstract: The present invention is directed to a system for producing and separating oil. The system comprises an oil-bearing formation, a low salinity aqueous fluid having an ionic strength of less than 0.15M and having a total dissolved solids content of from 200 ppm to 10000 ppm, a brine solution having a total dissolved solids content of greater than 10000 ppm, and a demulsifier. The system further comprises a mechanism for introducing the low salinity aqueous fluid into and oil-bearing formation, a mechanism for producing oil and water from the formation subsequent to introducing the low salinity aqueous fluid into the formation, and a mechanism for contacting the brine solution and the demulsifier with the oil and water produced from the formation and for separating the produced oil from the produced water.

Abstract: A wellbore servicing system comprising a flowpath comprising a first conduit from a water source to a mixer, a first fluid stream being communicated via the first conduit, the mixer, a wellbore servicing fluid being mixed within the mixer, and a second conduit from the fluid mixer to a wellbore, a wellbore servicing fluid stream being communicated via the second conduit, wherein at least a portion of the first fluid stream, the wellbore servicing fluid, the wellbore servicing fluid stream, or combinations thereof, are in contact with a quantity of template-assisted crystallization beads.

Abstract: A wellbore servicing composition comprising a base fluid, the base fluid comprising a substantially aqueous fluid, a brine, an emulsion, an invert emulsion, an oleaginous fluid, or combinations thereof, a quantity of template assisted crystallization beads, and a wellbore servicing fluid component, the wellbore servicing fluid component comprising a quantity of proppant, a quantity of gravel, or combinations thereof. A wellbore servicing system comprising a flowpath, the flowpath comprising at least one component of wellbore servicing equipment, and a conduit extending from the at least one component of wellbore servicing equipment to a wellbore, and a wellbore servicing fluid disposed within the flowpath, wherein the wellbore servicing fluid comprises a plurality of template assisted crystallization beads.

Abstract: A method includes treating a first formation intersecting a wellbore, preparing a diversion fluid including an inactivated viscosifier and an inactivated thinning agent, and positioning an amount of the diversion fluid to isolate the first formation. An activator is then delivered to the diversion fluid, thereby activating the inactivated viscosifier and triggering a thinning agent activation process.

Abstract: Methods and compositions for cementing are disclosed. Embodiments include a method of cementing comprising: providing a set-delayed cement composition comprising water, pumice, hydrated lime, a primary set retarder, a secondary set retarder; activating the set-delayed cement composition to produce an activated cement composition; introducing the activated cement composition into a subterranean formation; and allowing the activated cement composition to set in the subterranean formation.

Abstract: The present invention regards a device designed for injection of fluids in a well bore, typically an offshore well bore for petroleum production and gas injection/gas lift system for fluid injection. The device comprises a outer hollow housing (1) with an internal body (2) moveable within the outer housing (1) with an internal bore (3) which in a first closed position is closed with a metal to metal seal system between the outer housing (1) and the internal body (2), which internal body (2) is operated by pressure differential across the internal body (2), where the internal body (2) is designed with slots (4) forming outlets of the internal bore (3) which in an open position of the device is positioned outside of the outer housing (1).

Abstract: A fracturing system includes a fracturing spool that mounts onto a wellhead assembly for injecting fracturing fluid into a well beneath the wellhead assembly. The fracturing system includes an isolation sleeve and fracturing spool. The isolation sleeve inserts in an axial bore of the fracturing spool, and has a lower end that extends into the wellhead to isolate and protect portions of the wellhead assembly from the fracturing fluid. A groove in an inner surface of the fracturing spool receives an annular seal for sealing between the isolation sleeve and fracturing spool. Injecting a viscous fluid into the groove energizes the seal, and blocks high pressure fracturing fluid from flowing between the isolation sleeve and fracturing spool.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment a method a cementing in a subterranean formation comprising: providing a set-delayed cement composition comprising water, pumice, hydrated lime, and a set retarder; foaming the set-delayed cement composition; activating the set-delayed cement composition; introducing the set-delayed cement composition into a subterranean formation; and allowing the set-delayed cement composition to set in the subterranean formation. Additional methods, foamed set-delayed cement composition, and systems for cementing are also provided.

Abstract: A fracturing system includes a fracturing spool that mounts onto a wellhead assembly for injecting fracturing fluid into a well beneath the wellhead assembly. An isolation sleeve is included with the fracturing system that couples to the fracturing spool and extends into the wellhead to isolate and protect portions of the wellhead assembly from the fracturing fluid. A seal is between the isolation sleeve and bore of the wellhead assembly, which is threaded to the isolation sleeve. Manipulating the threaded connection between the isolation sleeve and seal selectively positions the isolation sleeve to designated axial positions within the wellhead assembly.

Abstract: A wellhead is provided. In one embodiment, the wellhead includes a plug for sealing a side passage of the wellhead. The plug may include an outer member, an inner member extending through the outer member and coupled to the outer member with at least one degree of freedom of movement relative to the outer member, and a moveable seal disposed around the outer member. In some embodiments, the moveable seal is configured to seal against the side passage in response to being moved on the outer member by the inner member.

Abstract: A chemical injection line connector includes first and second couplings configured to automatically seal shut when the members are disengaged. A method for blocking contamination or pressure transfer of chemical injection lines includes securing first and second couplings to corresponding ends of a chemical injection line and automatically sealing the couplings shut when the couplings are disengaged.

Abstract: A method of servicing a wellbore, comprising transporting a fluid treatment system to a wellsite, accessing a water source proximate to the wellsite, introducing a water stream from the water source into the fluid treatment system, irradiating at least a portion of the water stream within the fluid treatment system, wherein the portion of the water stream is irradiated by exposing the portion of the water stream to ultraviolet light emitted from at least one pulsed ultraviolet lamp, forming a wellbore servicing fluid from the irradiated water stream, and placing the wellbore servicing fluid into the wellbore.

Abstract: The present invention provides methods and apparatuses for the enhanced recovery of fluids from subterranean reservoirs using cryogenic fluids. Using the Earth's geothermal energy to warm cryogenic flood fluids injected into subterranean reservoirs, the pressure within the subterranean reservoir is increased. Consequently, the reservoir conductivity is enhanced due to thermal cracking, and improved sweep efficiency of the reservoir by the flood fluids is provided. This rise in pressure due to the injection of the cryogenic fluid increases the reservoir conductivity enhancement and improves sweep efficiency of the flood fluids, which leads to the production of more fluids from to the subterranean reservoirs.

Abstract: A method for fracturing a downhole formation, includes: preparing an energized fracturing fluid including mixing gaseous natural gas and a fracturing base fluid in a mixer; injecting the energized fracturing fluid through a wellhead and into a well; and continuing to inject the energized fracturing fluid until the formation is fractured. An apparatus for generating an energized fracturing fluid for use to fracture a downhole formation, the apparatus includes: a fracturing base fluid source; a natural gas source; and a mixer for accepting natural gas from the natural gas source and fracturing base fluid from the fracturing base fluid source and mixing the natural gas and the fracturing base fluid to generate the energized fracturing fluid.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 mol % dimethyl sulfide that is first contact miscible with a liquid petroleum composition is introduced into a petroleum bearing formation and petroleum and oil recovery formulation are produced from the formation. The produced oil recovery formulation is separated from the produced petroleum, and the produced oil recovery formulation is introduced into the formation.

Abstract: A method for fracturing a downhole formation, includes: preparing an energized fracturing fluid including mixing gaseous natural gas and a fracturing base fluid in a mixer; injecting the energized fracturing fluid through a wellhead and into a well; and continuing to inject the energized fracturing fluid until the formation is fractured. An apparatus for generating an energized fracturing fluid for use to fracture a downhole formation, the apparatus includes: a fracturing base fluid source; a natural gas source; and a mixer for accepting natural gas from the natural gas source and fracturing base fluid from the fracturing base fluid source and mixing the natural gas and the fracturing base fluid to generate the energized fracturing fluid.

Abstract: A system and process are provided for recovering petroleum from a formation. An oil recovery formulation comprising at least 75 mol % dimethyl sulfide that is first contact miscible with a liquid petroleum composition is introduced into a petroleum bearing formation and petroleum is produced from the formation.

Abstract: Gas Stream Production The present invention provides a method for the production of carbon dioxide and/or hydrogen gas streams, the method comprising: (i) thermally treating a feedstock material to produce a syngas comprising carbon monoxide and hydrogen and plasma-treating the syngas in a plasma treatment unit; (ii) reacting the plasma-treated syngas with water in a further treatment unit, whereby at least some of the carbon monoxide is converted into carbon dioxide; and (iii) recovering hydrogen and/or, separately, carbon dioxide from the syngas.

Abstract: The system includes a number of flexible fluid containment structures, or tubes, for storing fluids used in or produced during fracking. The tubes may be filled to store water prior to introduction into the well or drilling waste expunged from the well. A series of valves and pumps control the flow of fluids to and from the tubes, well, and purification equipment. A backflow preventer including a primary port, forward port, and return port supports bi-directional fluid transfer with the well. Drilling fluids are piped into the forward port and exit the primary port to the well. A flow meter may be coupled to the forward port to determine the volume of fluid flowing through the forward port to the well. Drilling waste may also return from the well via the primary port and exit the return port, which may also include a flow meter.

Abstract: A method of flocculating coal fines from produced water that includes the steps of: (A) mixing at least: (i) produced water, wherein the produced water comprises suspended coal fines; (ii) one or more oil-soluble phosphate esters; and (iii) water-immiscible solvent; wherein the mixing is in proportions to obtain an oil-in-water emulsion; (B) allowing or mechanically causing the oil-in-water emulsion to substantially break into: (i) a first fluid having a continuous phase comprising at least some of the water from the produced water; and (ii) a second fluid having a continuous phase comprising at least some of the water-immiscible solvent; and (C) mechanically separating the first fluid and the second fluid. Optionally, the step of mixing further includes mixing with a crosslinker for the one or more phosphate esters to form a gel for suspending the separated coal fines.

Abstract: Methods include the injection of a gelled, gelling or gellable composition into a horizontal section of a well at a location, where produced well gases or a combination of well gases and injected gases are sufficient to move the pill through the horizontal section into heal section, sweeping the horizontal section of accumulated liquids. Once in the heal section, the pill and the accumulated liquids are uplifted to the surface resulting in a cleaned well.

Abstract: A technique enables improved efficiency with respect to various coiled tubing and well servicing operations. The technique utilizes a combined mobile unit having several types of equipment combined into at least one transportable unit. The combined mobile unit may comprise a coiled tubing reel having coiled tubing, a well servicing system mounted to deliver material through the coiled tubing, and/or other well servicing components with the gas delivery system. The gas delivery system has a pressurized liquid gas vessel to deliver gas that can be used for well servicing operations, including purging material from coiled tubing.

Abstract: Fracturing headers and connected conduits are fit with one or more fluid screening and wear minimizing inserts. Tubular screen inserts are provided to screen a flow of fracturing fluid through manifolds prior to, or at, the fracturing header. Each tubular screen insert has a tubular wall having an insert bore, an endwall and an open inlet. A plurality of openings, about the tubular wall, provide fluid communication between the bore and an annular area outside the wall. Oriented in a flow conduit with the closed endwall upstream, the insert excludes and sheds debris therefrom. Oriented with the closed endwall downstream, the insert receives and stores debris. Pairs of inserts, retained in opposing inlet ports, serve to screen fluid and deflect erosive flow from tools such as coil tubing extending therethrough. A fracturing block fit with opposing inlet ports can also be fit with an outlet port for flowback operations.

Abstract: A fracturing method comprises: pumping a first stream of liquefied petroleum gas and gelling agent with a first frac pressure pump; pumping a second stream of lubricated proppant with a second frac pressure pump; combining the first stream and the second stream within a wellhead into a combined stream, pumping the combined stream into a hydrocarbon reservoir; and subjecting the combined stream in the hydrocarbon reservoir to fracturing pressures. A fracturing apparatus comprises: a first frac pressure pump connected to a first port of a wellhead; a second frac pressure pump connected to a second port of the wellhead; a frac fluid source connected to simply a stream of frac fluid comprising liquefied petroleum gas to the first frac pressure pump; a gel source connected to supply a gelling agent into the frac fluid; and a proppant supply source connected to supply lubricated proppant to the second frac pressure pump.

Abstract: Systems and methods relate to treating wastewater, such as blowdown from steam generators used in oil sands production. The systems rely on precipitation by acidification of the wastewater along with passing the wastewater at a pressure of at least 138 kilopascals through a multiphase centrifuge to remove at least partially organic and/or silica solids. A resulting treated aqueous stream may meet thresholds desired for injection into a disposal well.

Abstract: Described herein is a modular, adjustable system for distributing fluids to one or more wellbores. The system is readily configured and assembled at a well site, and allows for one portion of the system to be isolated for service or repair while the remainder of the system continues to operate. The system includes a plurality of pump skids having both a distribution junction in fluid communication with inlets to of plurality of pump trucks and an exit junction in fluid communication with outlets of the plurality of pump trucks.

Abstract: A multiple activation-device launching system for a cementing head comprises a launcher body and at least one launching chamber that are sized to receive one or more activation devices therein. The activation devices are launched into the principal process-fluid stream inside the cementing head, and may be darts, balls, bombs, canisters and combinations thereof. The launching chambers are in fluid communication with an external power source for launching the activation device into the principal process-fluid stream.

Abstract: A system comprising a well drilled into an underground formation comprising hydrocarbons; a water supply; a steam production facility, the steam production facility comprising a filter to remove at least 80% of a quantity of divalent cations in the water supply; an exchange resin to remove at least 80% of a quantity of divalent cations in a filtered water stream that has already passed through the filter; a steam injection facility connected to the well and the steam production facility, adapted to inject the steam into the well.

Abstract: A mobile manifold assembly of a fluid system for providing fluid to a wellsite during well construction. The fluid system includes auxiliary components including at least one fluid source, mixer and high pressure pump. The manifold assembly includes a modular manifold and a mobile frame. The modular manifold includes manifold pumps, valves and pipes integrated together for transport. Connector portions of the pipes extend from the modular manifold in an arrangement corresponding to an arrangement of the auxiliary components to define a plug-in configuration therebetween such that the connector portions of the pipes are positionable in alignment with the auxiliary components for direct and removable connection therewith. The manifold pumps and valves are positioned about the pipes to selectively pump the fluid. The modular manifold is securable to a base of the mobile frame whereby the modular manifold is transportable to the auxiliary components for operable connection therewith.

Abstract: An underwater placed assembly produces gas or gas and oil/condensate from a subsea gaseous reservoir, where at least one production well is provided from the seabed to a production zone and at least one water injection well is provided from the seabed to an injection zone. The assembly includes: a pressure increasing device connected to the outlet of the production well in order to increase the pressure in a production flow from the production well, and a water turbine that is connected to and driving the pressure increasing device.

Abstract: Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus. Embodiments may include determining the boundary between a cement composition and a consolidating spacer fluid based on presence of tagging material in the well bore.

Abstract: The purpose of this invention is to improve on the safety and to allow more efficient production of subterranean formation during fracturing operations with a reduced down-time, minimal supervision and maintenance expense by utilizing remotely operated ground valves having metal-to-metal, gate and seat seal design operable to maintain a dual sided flow and pressure control. Use of a new 45-degree flow-T connector of a Zipper Manifold in combination with the system described is particularly useful for reducing erosion with proppant-laden fracturing fluid.

Abstract: The current application discloses methods and systems for preparing a pump-ready treatment fluid, delivering the pump-ready treatment fluid to a location operationally coupled to a wellsite, providing the pump-ready treatment fluid to a pump; and pumping the pump-ready treatment fluid into a wellbore. In some embodiments, the treatment fluid is a fracturing fluid for conducting a hydraulic fracturing operation on a subterranean formation penetrated by a wellbore.

Abstract: Embodiments disclosed herein relate to an apparatus to fluidly couple to a casing string. The apparatus may include a fill-up and circulating tool having a flow path extending therethrough, in which the fill-up and circulating tool may be configured to fluidly seal internally within an upper end of the casing string. The apparatus may further include a cementing head assembly having a flow path extending therethrough, in which the flow path of the cementing head assembly is fluidly coupled to the flow path of the fill-up and circulating tool, and a releasing mechanism coupled to the cementing head assembly, in which the releasing mechanism is configured to release a fluid-conveyed sealing device through the cementing head assembly and into the fill-up and circulating tool.

Abstract: Methods and systems of fracturing subterranean formations are provided comprising pumping metacritical phase natural gas into a subterranean formation to create or extend one or more fissures in the formation. Methods and systems may further comprise maintaining or increasing pressure of the metacritical phase natural gas in the formation by pumping more metacritical phase natural gas into the fissures to hold the fissures open. Methods and systems may further comprise delivering a proppant into the subterranean formation. Disclosed methods and systems may be used to extract hydrocarbons from subterranean formations without the use of liquids.

Abstract: An automatically controlled methanol injection system for oil and gas production streams including an electric methanol injection pump and a temperature sensor and switch, the sensor and switch adapted to automatically adjust the injection of methanol as a function of sensed temperature.

Abstract: A method of drilling into a geological region including a subsurface clathrate reservoir includes drilling a borehole into the geological region including the subsurface clathrate reservoir and dissociating at least a portion of the clathrate in a region near the borehole. After the dissociating, material within at least a portion of the region near the borehole in which the clathrate has been dissociated is compacted to form a compacted region at least partially surrounding the borehole within the clathrate reservoir. After the compacting, well casing is placed into the borehole within the compacted region and the well casing is cemented into the borehole in the compacted area.